JP7368480B2 - Vapor sample concentration and preparation for online vapor purity analysis - Google Patents

Description

Detailed description of the invention

[Field of invention]
TECHNICAL FIELD This application relates to steam sample concentrator and conditioning (SSCC) systems and methods of using the same.

(Cross reference to related applications)
This application claims the benefit of U.S. Patent Application No. 16/246,961, filed January 14, 2019, the contents of which are incorporated herein by reference.

[Background technology]
Steam used in fossil fuel power plants, nuclear power plants, and geothermal power plants contains impurities such as silica, sodium, chloride, iron, and solid particles, which can lead to corrosion of power plant equipment, especially steam turbines. , which can cause scaling and erosion. Steam is also used in other industrial processes, such as enhanced oil recovery (e.g., steam flood injection), heating, cooling, food processing, and medical sterilization applications, and may contain impurities that are harmful to the process. Impurities are present as dissolved species in liquid water droplets entrained in the vapor or as solid particulate material. Volatile silica and chlorides can be present in hot saturated steam or in superheated geothermal steam produced from geothermal wells feeding deep, high temperature reservoirs of water and/or steam. Determining the amount of these impurities in the steam is important for process control and for successfully implementing mitigation measures to improve steam purity and prevent equipment damage.

Impurities carried in droplets or as solid particles have a much higher density than the surrounding gaseous vapor phase. Isokinetic sampling is required to obtain representative samples, followed by specialized analytical techniques for low-level detection in the presence of various interfering species in vapor condensate samples. . Geothermal steam contains _H2S and _CO2 , which cause significant interference in most analytical methods required for laboratory and on-line analysis of steam impurities. Sodium, silica, chloride and iron typically need to be measured at concentrations down to 10 ppb or less in steam to prevent scaling, erosion and corrosion in steam turbines and other process equipment. be. Detection at these levels can be very difficult, especially in the presence of interfering species. Commercially available analyzers can reach these detection limits in ultrapure steam condensates free of dissolved gases, but not reliably in process steam, and never in raw geothermal steam.

Online measurement of steam purity is a well-established technique considered important for power generation and other industrial processes that utilize steam. Conventional techniques involve 100% condensation of vapor samples, typically collected isokinetically. The vapor is completely condensed and the resulting liquid condensate is subcooled (below the vapor saturation temperature at the condensing pressure) in a continuous one-step process through a helical tube heat exchanger with the vapor. Steam flows inside the tube (tube side) and cools the water outside the tube (shell side). The concentration of impurities by mass measured in this fully condensed vapor condensate is the same as in the pipeline from which it was extracted or the bulk vapor stream being processed. There is no correction required for mass dilution or concentration to reduce the impurity concentration of the condensed sample back to the original vapor.

In the process of completely condensing a vapor sample and subcooling the condensate, a two-phase mixture of liquid vapor condensate and non-condensable gas is produced. Non-condensable gases pass through the condensate into the condensate in proportion to their partial pressure and solubility constant at the condensate outlet temperature, which is typically 20-30°C (well below the boiling point at 1 atm). dissolve in Under these conditions, H ₂ S and CO ₂ are highly soluble. In geothermal applications, these gases, after being dissolved in the conventional condensation process described above, are removed from the condensate by purging the subcooled condensate with nitrogen and reheating the condensate (below the boiling point). Efforts have been made to pass the condensate and/or the condensate through a degassing membrane where the dissolved gases permeate through the membrane resulting in a higher purity gas stream, such as nitrogen. Critical to the success of impurity measurements in geothermal steam, particularly silica measurements, is the effective removal of _H2S when _NH3 is present in the steam. Conventional techniques are insufficient to completely remove H ₂ S and prevent analytical interference when NH ₃ is present. This is because the dissolution of highly soluble _NH3 gas increases the pH of the condensate, leading to the ionization of _H2S to bisulfide ions:
NH ₃ + H ₂ O → NH ₄ + OH ⁻
OH ^- + H ₂ S → H ⁺ + HS ^-
Since bisulfide ions are ions and have no vapor pressure, they cannot be purged or degassed from the condensate. The only means by which _H2S can be completely purged from the condensate after a conventional condensation step is to reduce the pH to below 3.0 by adding acid, which converts all bisulfides into _H2S . To return:
H ⁺ + HS ⁻ → H ₂ S. .

[Summary of the invention]
The present invention provides a steam sample concentration and conditioning (SSCC) system (eg, for pretreating steam prior to analysis and/or use). SSCC is used to concentrate impurities carried in steam (e.g. used in power generation and other industrial processes), and to concentrate impurities carried in the steam, such as sodium (Na), silica ( _SiO2 ), chloride (Cl), iron (Fe). , and total suspended solids (TSS) (e.g., at parts per billion (ppb) level). SSCC may also be used to prevent noncondensable gases (NCG) from steam (e.g., geothermal steam) from dissolving into condensate that would interfere with steam analysis, thereby preventing allows accurate measurement of impurities.

Accordingly, in some embodiments, the invention provides a steam sample concentration conditioning (SSCC) system and methods of using the same, as disclosed and described herein. In some embodiments, the SSCC system concentrates impurities carried in the vapor. The present invention is not limited by the type of impurity that is concentrated. Exemplary impurities that are concentrated include sodium (Na), silica ( _SiO2 ), chloride (Cl), iron (Fe), total suspended solids (TSS), or other impurities known in the art. These include, but are not limited to: In some embodiments, the impurity or impurity is one that causes corrosion, scaling, and/or erosion of equipment (eg, power plant equipment (eg, steam turbine)). In some embodiments, impurities are present as dissolved species (eg, in droplets in a vapor). In other embodiments, the impurity is present as solid particulate material. The present invention is not limited by the type of steam that is treated (eg, pretreated) using the SSCC system of the present invention. In some embodiments, the steam is steam used to generate electricity (eg, geothermal steam). Examples of other types of steam processed include steam used for oil recovery (e.g. steam flood injection), steam used for heating, steam used for cooling, steam used for food processing. , and steam used in medical sterilization applications.

In some embodiments, the SSCC system facilitates analysis of one or more impurities present in the vapor (eg, that would interfere with analysis of the vapor sample). The invention is not limited by the type or source of the impurity or impurities analyzed. Exemplary impurities analyzed include sodium (Na), silica ( _SiO2 ), chloride (Cl), iron (Fe), total suspended solids (TSS), or other impurities known in the art. These include, but are not limited to: In some embodiments, the analysis determines the amount or level of one or more impurities in the vapor. The invention is not limited by the level of impurity that is measured, detected, and/or determined. In some embodiments, analysis (eg, measurement and/or detection) of impurities is performed at parts per billion (ppb) levels. However, the invention is not limited thereto. The range of impurities measured, detected, and/or determined in the steam can range from about 0.1 ppb to more than about 10,000 ppb, but less (e.g., less than 0.1 ppb) and more (e.g., 10,000 ppb) can be measured, detected, and/or determined. In some embodiments, the SSCC system concentrates impurities carried in the vapor to facilitate analysis (eg, measurement and/or detection) of the impurities. In some embodiments, determining the amount of one or more impurities in the steam provides superior process control. In other embodiments, determining the amount of one or more impurities in the steam makes implementing mitigation measures impossible without accurately determining the amount of one or more impurities. (e.g., to improve steam purity and/or prevent equipment damage).

In some embodiments, SSCC systems are used to prevent dissolution of noncondensable gases (NCG) in geothermal steam. In some embodiments, by preventing the dissolution of NCG in the vapor, the difference between the vapor sample (e.g., the condensate phase and the non-condensable A more accurate measurement of NCG in the sample (after separation from the gas phase) becomes possible. The invention is not limited by the type of NCG (eg, its dissolution in vapor is prevented). In some embodiments, NCG is hydrogen sulfide ( _H2S ). In some embodiments, NCG is carbon dioxide ( _CO2 ). In some embodiments, the NCG is a mixture of gases (eg, _H2S and _CO2 , _H2S and _CO2 and one or more other gases).

The invention also provides a method of analyzing a sample (eg, a vapor sample or a portion thereof (eg, a vapor stream sample)) using the SSCC system of the invention. In some embodiments, vapor samples are collected (eg, using a stationary multi-nozzle isokinetic sample probe). In some embodiments, a sample (eg, a sample stream) is directed under pressure through tubing (eg, stainless steel tubing) to the SSCC system. In some embodiments, the sampling point and the SSCC system are separated by about 1-50 meters (m), about 5-25 m, about 5-15 m, about 7-15 m, or about 7-10 m. In some embodiments, the SSCC is within about 10 meters from the sampling point. In some embodiments, the flow rate of the vapor sample is adjusted (eg, using a critical flow device) to maintain isokinetic flow conditions. The invention is not limited by the type of flow device used. Exemplary flow devices include, but are not limited to, differential pressure orifice meters, critical flow orifices, vortex flow meters, Coriolis flow meters, and thermal mass flow meters. In yet other embodiments, a slow heat pump recirculates the condensate to ensure that the sample remains saturated and does not deposit impurities upstream of the analyzer. In some embodiments, a metering pump administers acid to the sample stream after the simmer. The invention is not limited by the type of acid introduced into the sample stream via the metering pump. Exemplary acids include, but are not limited to _, HCl, _H2SO4 , acetic acid, and citric acid. In some embodiments, the acid is a dilute acid (eg, a concentrated acid diluted by addition to water). In some embodiments, the vapor sample is condensed (e.g., partially condensed) in a single tube shell-and-tube heat exchanger under a controlled (e.g., precisely controlled) condensation process. . In further embodiments, the rate of condensate produced is adjusted (eg, automatically by varying the flow rate of cooling water through a single tube heat exchanger) to a desired set point. The invention is not limited by the fraction of condensate produced. In some embodiments, the fraction is about 2-50% of the total sample vapor flow. In other embodiments, the fraction is about 5-10% of the total sample vapor flow. Impurities (e.g., sodium (Na), silica (SiO ₂ ), chloride (Cl), iron (Fe), total suspended solids (TSS), and/or other desired impurities) are removed from the condensing temperature (e.g., 100 -150°C), impurities are concentrated during processing (eg, 2-50 times). In some embodiments, a high temperature partial condensation step in which acid is added to maintain the pH below 3.0 prevents non-condensable gases from dissolving (e.g., necessary to later degas the condensate). steps and/or resources (e.g. _H2S )). In some embodiments, the separated NCG is measured by a mass flow meter to determine the NCG concentration in the steam. In further embodiments, the concentrated and degassed liquid sample is pumped to an on-line analyzer (eg, for measurement of sodium, silica, chloride, iron and/or turbidity levels).

The SSCC systems and methods of using the same provided in some embodiments of the present invention have unique and fundamental advantages for online monitoring of steam purity (eg, geothermal steam purity). In some embodiments, systems and methods using those described herein allow for sample preconcentration of an order of magnitude or more (eg, 10-20 times) above the raw level in the vapor. In further embodiments, systems and methods using those described herein include a sample condensation step that prevents dissolution of interfering species (e.g., <0.1% of _H2S and _CO2 in the vapor). is dissolved in the condensed sample). In still further embodiments, condensation without gas dissolution enables highly accurate NCG measurements not possible without the systems and methods disclosed herein. In yet other embodiments, systems and methods using those described herein include isokinetic sample flow control (e.g., using a critical flow orifice or automatic flow control valve to control the flow rate of sample vapor). controlling thereby ensuring that the isokinetic probe is operated at the correct flow rate to produce representative samples of vapor and liquid and/or particulate impurities). In yet other embodiments, the systems and methods of use described herein eliminate the need for air and/or nitrogen purging (eg, required for interference removal). Systems and methods using those described herein also eliminate the need for ion exchange cartridges (eg, required for preconcentration or preprocessing) in some embodiments.

[Brief explanation of the drawing]
FIG. 1 is a diagram illustrating the main components and subcomponents and overall structure of an SSCC system in one embodiment of the invention connected to an online stream purity analyzer.

FIG. 2 is a diagram illustrating major components and subcomponents with electrical analog and digital signal connections (dashed lines, control inputs and signal outputs) between the components of the SSCC system in an embodiment of the invention. .

FIG. 3 shows the calculated residual CO ₂ dissolved in fully condensed vapor as a function of the amount of N ₂ purge gas to degas the condensate, with and without acid addition for pH adjustment.

Figure 4 shows the calculated residual _H2S dissolved in fully condensed vapor as a function of the amount of _N2 purge gas to degas the condensate, with and without acid addition for pH adjustment. .

FIG. 5 shows the measured residual H ₂ S dissolved in a real steam condensate sample as a function of the amount of N ₂ purge gas, with and without acid addition for pH adjustment.

Figure 6 shows the results from a model of the SSCC process for residual _H2S dissolved in partially condensed steam at 100 °C as a function of acid addition for pH adjustment, using the same model and steam composition as Figures 3 and 4. Show the calculation results.

FIG. 7 shows the results of a test performed on the SSCC using a vapor test loop to determine the amount of liquid carryover from separator 9 to vapor. Figure 7 shows that the amount of liquid carried over by vapor from the separator was only about 0.2%.

FIG. 8 shows the results of a test conducted to directly measure the concentration factor and recovery efficiency of steam impurities by the SSCC process. Figure 8 shows that under the conditions tested, the expected concentration of Na in the condensate was 1.02 ppm and the average measured concentration by the online sodium analyzer was 0.99 ppm.

(Detailed description of the invention)
The present invention relates to a steam sample concentration conditioning (SSCC) system. SSCC systems concentrate impurities carried in the vapor and facilitate analysis of the impurities. Preventing non-condensable gases (NCGs) such as hydrogen sulfide ( _H2S ) and carbon dioxide ( _CO2 ) from dissolving into geothermal steam and interfering with steam analysis. For example, when analyzing vapor, the vapor is often separated into a condensable gas phase and a non-condensable gas phase. By preventing the dissolution of NCG in the vapor sample after separation of the condensable and non-condensable gas phases, the SSCC system of the present invention allows significantly more accurate measurements of impurities in the sample compared to conventional systems. Make it.

The SSCC system of the present invention can be configured to interface with commercially available online analytical instruments for impurity analysis. Non-limiting examples of commercially available analytical instruments include the Hach (Hach, Loveland, CO, USA) Model 9245 Low Level Sodium Analyzer, based on an ion-specific electrode (ISE); the Hach Model 5500sc Low Level Silica Analyzer, based on color spectrophotometry. a Hach model EZ2005 low-level total iron analyzer based on color spectrophotometry; and/or a Hach model TU5300 low-level turbidity (TSS) analyzer based on laser light scattering.

The concentrated, interference-free liquid sample produced by the SSCC system provided to the analyzer increases the reliability of online vapor purity measurements by reducing the chance of false-positive results for impurities and the bias toward falsely elevated values. Significantly improve sex. This is common when measurements are made on untreated samples due to contamination by these same compounds found ubiquitously in the environment and the aforementioned interference from dissolved gases. Accordingly, the SSCC system disclosed herein includes: 1. increasing the sample concentration by an order of magnitude directly in the sample collection process; and 2. By preventing NCG dissolution, reducing and/or eliminating false positive readings (e.g. caused by impurities and by biasing to falsely elevated levels) and/or reducing conventional vapor sample analysis. Reduce and/or eliminate interference from dissolved gases (eg, H ₂ S and/or CO ₂ ) associated with the system.

Certain illustrative embodiments will now be described to provide a thorough understanding of the structure, function, manufacture, and principles of use of the systems and methods disclosed herein. One or more examples of these embodiments are illustrated in the accompanying drawings. Those skilled in the art will appreciate that the systems and methods specifically described herein and illustrated in the accompanying drawings are non-limiting exemplary embodiments. The features illustrated or described in connection with one exemplary embodiment may be combined with the features of other embodiments. Such modifications and variations are intended to be included within the scope of this invention.

A non-limiting example of the SSCC system of the present invention is shown in FIG. The same example is shown in FIG. 2, along with electrical signal and control interconnections with a programmable logic control (PLC) system.

In one embodiment of the present invention, as shown in FIGS. 1 and 2, the main components and subcomponents of the SSCC system are numerically listed below to briefly explain their functions and interrelationships in the SSCC of the present invention. Explain to:
1. Constant velocity probe.
a. In some embodiments, SSCC is used to extract a representative sample (mixture) of liquid-solid phase impurities in steam from an isokinetic probe (e.g., a power plant/pipeline through which process steam flows). )including.
2. Isolation valve for constant velocity probe a. In some embodiments, the SSCC includes an isolation valve (eg, utilized to isolate the vapor sample flow from the isokinetic probe to the SSCC).
3. Steam sample line to SSCC.
a. In some embodiments, the SSCC includes a vapor sample line (eg, a piping conduit for vapor sample flow from the probe to the SSCC).
4. Isolation valve to prevent heating of condensate injection into the vapor sample line.
a. In some embodiments, the SSCC includes a vapor sample line (e.g., to enable sequestration of condensate that is recycled back into the vapor sample flow to the SSCC (e.g., for the purpose of preventing the vapor sample from overheating)). Contains isolation valve for desuperheat condensate injection into.
5. Piping that slows the condensate from the slow heat pump.
a. In some embodiments, the SSCC includes piping that provides a conduit for recycled condensate from the sample cooler and back to the vapor of the vapor sample stream.
6. Steam sample line pressure sensor.
In some embodiments, the SSCC measures pressure upstream of a pressure sensor (e.g., a steam sample flow meter (e.g., for flow rate calculations) and/or transmits a signal to a programmable logic controller (PLC) configuration of the SSCC. ).
7. Steam sample flow meter.
a. In some embodiments, the SSCC includes a flow meter (e.g., to measure the flow rate of the steam sample (e.g., to calculate and/or adjust the % isokinetic flow rate and the steam sample concentration factor) and/or sending signals to the SSCC's PLC).
8. Vapor sample flow control valve/isolation valve.
a. In some embodiments, the SSCC controls the flow rate of the vapor sample based on input signals from a flow control valve/isolation valve (e.g., a PLC (e.g., maintains a constant flow rate close to 100%). (e.g., automatically isolating the vapor sample flow when the vapor sample line and/or system or process causes an alarm condition).
9. Steam sample temperature sensor.
a. In some embodiments, the SSCC includes a temperature sensor (eg, that measures the temperature downstream of a flow meter of a sample of steam and sends a signal to a PLC for steam saturation/superheat calculations).
10. Pressure switch for contactor cooling water supply.
a. In some embodiments, the SSCC includes a pressure switch (eg, that measures cooling water pressure to the contactor and/or sends an alarm to the PLC if the pressure is below a preset value).
11. Temperature sensor for contactor cooling water supply.
a. In some embodiments, the SSCC detects a temperature sensor for the contactor cooling water supply (e.g., measures the cooling water temperature to the contactor and/or detects a value if it exceeds a preset value). to the PLC and cause an alarm).
12. Check valve for contactor cooling water supply.
a. In some embodiments, the SSCC includes a check valve (e.g., contactor cooling water supply (e.g., to prevent backflow of cooling water from the contactor)).
13. Steam contactor.
a. In some embodiments, the SSCC provides controlled heat transfer from a sample of steam to cooling water (e.g., non-volatile impurities that are cleaned (contacted) from a sample of steam) in a steam contactor (e.g., (concentrated, providing a certain amount of condensed vapor)).
14. Flow control valve for contactor cooling water outlet.
a. In some embodiments, the SSCC uses a flow control valve at the outlet for contactor cooling water (e.g., to maintain a target amount of condensed water (e.g., via programmed logic)) controlling the water flow rate (e.g., based on input signals from the PLC to maintain the target condensate flow rate).
15. Temperature sensor at contactor cooling water outlet.
a. In some embodiments, the SSCC detects a temperature sensor for the contactor cooling water outlet (e.g., measures the cooling water temperature from the contactor outlet and/or outputs a value if a preset value is exceeded). to the PLC and cause an alarm).
16. Steam/condensate separator.
a. In some embodiments, the SSCC includes a vapor/condensate separator (e.g., separating condensate from residual vapor exiting the contactor (e.g., by centrifugal action, inertial separation, and wire mesh media capture)).
17. Separator pressure sensor.
a. In some embodiments, the SSCC uses a pressure sensor at the separator (e.g., measures the pressure at the separator outlet and/or sends the value to the PLC and triggers an alarm if a preset value is exceeded). including.
18. Separator condensate dump valve.
a. In some embodiments, the SSCC installs a condensate dump valve in the separator that removes excess condensate from the separator (based on an input signal from the PLC, e.g., if a high level alarm is triggered in the accumulator). (e.g., via programmed logic).
19. Plumbing separator condensate to sample cooler.
a. In some embodiments, the SSCC includes piping for the transfer of separator condensate to the sample cooler (e.g., a piping conduit for condensate from the separator to the sample cooler, connected to the accumulator). including.
20. Accumulator level sensor.
a. In some embodiments, the SSCC has a level sensor in an accumulator component of the SSCC (e.g., measures the level in the accumulator, enables control of a VSD condensate pump, and/or has certain level sensors in the accumulator and separator). sending signals to the PLC) to maintain the liquid level.
21. accumulator container.
a In some embodiments, the SSCC includes an accumulator vessel (eg, providing a flow turbulence-free vessel that reflects the same liquid level as the separator).
22. Condensate sample cooler.
a. In some embodiments, the SSCC collects the condensate from a condensate sample cooler (e.g., a single tube heat exchanger or equivalent, e.g. cooling the sample)).
23. Flow control valve at the cooling water outlet of the condensate sample cooler.
a. In some embodiments, the SSCC includes a flow control valve at the cooling water outlet of the condensate sample cooler (eg, providing manual flow control for cooling water to the sample cooler).
24. Condensate sample cooler cooling water outlet piping.
a. In some embodiments, the SSCC includes piping for a condensate sample cooler cooling water outlet (eg, providing a conduit for draining cooling water from the sample cooler).
25. Condensate sample cooler cooling water inlet isolation valve.
a. In some embodiments, the SSCC includes an isolation valve for the condensate sample cooler cooling water inlet (eg, to allow manual isolation of the amount of cooling water circulated to the sample cooler).
26. Flow switch on the cooling water inlet of the condensate sample cooler.
a. In some embodiments, the SSCC measures the flow of the cooling water inlet of the condensate sample cooler (e.g., the flow of the cooling water to the sample cooler and/or the flow is set to a preset value). (sends an alarm to the PLC if the
27. Condensate sample cooler cooling water inlet piping.
a. In some embodiments, the SSCC includes piping for a cooling water inlet of a condensate sample cooler (eg, providing a conduit for cooling water flow to the sample cooler).
28. Condensate sample temperature sensor.
a. In some embodiments, the SSCC measures the temperature of the condensed sample downstream of a condensate sample temperature sensor (e.g., a sample cooler) and/or detects the temperature of the condensed sample if the temperature exceeds a preset value. to the PLC and trigger an alarm).
29. Piping outlet for condensed sample from the cooler.
a. In some embodiments, the SSCC includes tubing from a condensate sample cooler (eg, providing a conduit for cooling the water stream exiting the sample cooler).
30. Slow heat pump.
a. In some embodiments, the SSCC includes a slow heat pump (e.g., pumps a portion of the condensate from the sample cooler back into the vapor sample stream to the SSCC (e.g., slow heats the vapor sample)). include.
31. Flow control valve/isolation valve for air supply for slow heat pumps.
a. In some embodiments, the SSCC includes a flow control valve/isolation valve for the air supply in the slow heat pump (eg, allowing control of the compressed air supply to drive the slow heat pump).
32. Condensate sample pump with variable speed drive.
a. In some embodiments, the SSCC includes a condensate sample pump (e.g., a pump with variable speed drive (e.g., at a speed proportional to a signal from a PLC) (e.g., controls and maintains a constant liquid level in the accumulator and separator). pumping the condensate from the accumulator vessel (through a sample cooler).
33. Piping the condensed sample to the analyzer.
a. In some embodiments, the SSCC includes piping for delivering a sample of condensate to an analyzer (eg, providing a conduit for cooled and pumped condensate to the analyzer).
34. 3-way valve for condensed sample to analyzer or drain tube.
a. In some embodiments, the SSCC has a valve (e.g., 3-way valve) for the condensate sample to the analyzer or drain (e.g., via programmed logic in the PLC) and/or (allowing the cooled and pumped condensate sample stream to evacuate while the water flows to the analyzer).
35. Flow sensor for condensed sample to analyzer.
a. In some embodiments, the SSCC includes a flow sensor in the analyzer (eg, to measure the flow rate of the condensate sample and/or send a signal to the PLC to calculate the vapor sample concentration factor).
36. Deionized water piping to the analyzer.
a. In some embodiments, the SSCC includes plumbing for deionized water to the analyzer (eg, provides a conduit for deionized water to the analyzer).
37. Deionized water isolation valve.
a. In some embodiments, the SSCC includes an isolation valve for deionized water (e.g., allowing the deionized water to flow to the analyzer under the control of the PLC's programmed logic).
38. Deionized water ion exchange cartridge.
a. In some embodiments, the SSCC runs an ion exchange cartridge (e.g., removes dissolved ions and other impurities from a deionized water supply (e.g., generates and runs a high purity deionized water source) and produces a zero baseline water supply. flow to the analyzer)).
39. Steam impurity analyzer.
a. In some embodiments, the SSCC includes one or more vapor impurity analyzers (e.g., commercially available online vapor purity analyzers that measure impurity levels (e.g., Na, Cl, _SiO2 , Fe, and TSS analyzers) )including.
40. Steam impurity analyzer sample discharge piping.
a. In some embodiments, the SSCC includes drain piping from the vapor purity analyzer (eg, provides a conduit for liquid to drain from the analyzer).
41. Programmable logic control (PLC) system.
a. In some embodiments, the SSCC receives input signals (e.g., from measurement equipment) from one or more PLC systems (e.g., from measurement equipment) and receives control signals (e.g., from valves, pumps, analyzers, and/or power plant controls). (provides computer-based control of the SSCC).
42. Human Machine Interface (HMI).
a. In some embodiments, the SSCC includes an HMI (e.g., a PLC connected thereto and means for programming and controlling the SSCC components (e.g., a touch screen display or the like)).

The following describes how the various components of the SSCC system of the present invention (e.g., as shown in Figures 1 and 2) work together to concentrate impurities carried in the vapor and to facilitate analysis of the impurities. Explain how it works. Note that the SSCC system of the present invention is not limited to the following example.

Vapor sample extraction. A steam sample is extracted from a steam pipeline (eg, a geothermal steam pipeline carrying raw geothermal steam) using a multi-nozzle isokinetic sample probe 1 . In some embodiments, a multi-nozzle probe is used that provides an integrated sample of liquid and solid phase impurities entrained in the vapor across the diameter of the pipeline. The Model SQ2000 multi-nozzle isokinetic vapor sampling probe from Thermochem (Santa Rosa, Calif., USA) is specifically designed for this purpose. Other single nozzle isokinetic steam sampling probes can be used, such as those specified in ASTM D 1066-06, "Standard Practice for Sampling Steam." In embodiments, the multi-nozzle isokinetic sample probe has a sample flow rate under isokinetic conditions (i.e., the ambient vapor velocity in the pipeline and the vapor inlet velocity into the nozzle are the same) of at least 1000 g/min. be made to a certain size. However, the invention is not limited thereto. For example, in some embodiments, the systems and methods of the present invention are useful under isokinetic sample flow rates of about 100 g/min to about 10,000 g/min. In some embodiments, the sample flow rate at the minimum concentrated liquid condensate outlet of the vapor purity analyzer is about 10 g/min. The usable range of concentrated liquid condensate streams is 10 g/min to 1,000 g/min. Thus, in one embodiment, if the total inlet vapor sample flow rate is 1000 g/min and the concentrated liquid condensate sample flow rate to the vapor purity analyzer is 50 g/min, then the SSCC system has a concentration factor of 20 (i.e. , which is 20 times more concentrated than the feed inlet vapor flow rate). The invention is not limited to any particular enrichment factor. Indeed, in some embodiments, the inlet vapor sample flow rate and the vapor purity analyzer flow rate are varied to provide a desired enrichment factor, where the enrichment factor is from about 3 to about 50, from about 5 to 30, about 10 to 20, any value between 3 and 50, or any value below 3 (e.g., 1.5, 2, 2.5) or above 50 (e.g., 60, 75 , 90, etc.). In a preferred embodiment, the enrichment factor is a value between 10 and 20. In some embodiments, high vapor sample flow rates are utilized (e.g., 2000-10,000 g/min) by using larger isokinetic nozzle diameters (e.g., 5 mm to 25 mm), thereby The incidence of nozzle clogging by solids entrained therein is reduced.

In some embodiments, the SSCC system includes a component that measures the flow rate of the steam inlet sample. In some embodiments, the flow rate of the steam inlet sample is measured by a critical orifice meter, a vortex meter, and/or a thermal mass flow meter 7. In some embodiments, if a critical orifice meter is used, the critical orifice meter provides flow regulation of the vapor sample (eg, as required to maintain constant velocity conditions). The flow rate of the vapor sample is linearly proportional to the upstream orifice pressure. The upstream orifice pressure is essentially the same as the steam pipeline pressure, but can be measured directly by a pressure transducer 6 in the steam sample line 3. In embodiments where vortex flowmeters and/or thermal mass flowmeters are used in the SSCC system, the system also includes a flow control valve 8.

In some embodiments, the SSCC system partially condenses the vapor sample stream. The invention is not limited by the amount of partial condensation. In practice, the SSCC system reduces the vapor sample flow by about 2-50%, about 5-40%, about 5-30%, about 5-25%, or about 5-20%, or any value therebetween. can only be condensed. In a preferred embodiment, the SSCC system condenses the vapor sample stream by about 5-20% by weight to produce a concentrated condensed sample stream (eg, rich in impurities). The invention is not limited by the amount of concentration. The concentration level of impurities can be controlled and varied by controlling the amount of condensation of the sample stream. For example, if a sample stream is condensed by about 5-20% by weight by the SSCC system of the present invention, this produces a highly concentrated condensed sample stream rich in impurities.

Let the steam sample concentration factor be X, where X = steam inlet sample flow rate/condensate outlet sample flow rate. In some embodiments, the partial condensation process is controlled by adjusting the cooling water flow rate within a single tube shell tube heat exchanger called contactor 13. In such embodiments, the cooling water supply pressure must exceed the saturation pressure of the steam sample to prevent boiling of the cooling water on the shell side of the heat exchanger. Typically, the vapor pressure within the contactor is between 1.5 and 2.0 bar (bara). The flow rate of cooling water through the contactor is regulated at the outlet by an automatic flow control valve 14 (operated, for example, by an electronic stepper motor or pneumatic control). Such a configuration ensures that the pressure of the cooling water in the contactor is the same as the cooling water inlet pressure and exceeds the steam sample saturation pressure, thereby preventing boiling of the cooling water in the contactor. In this way, boiling of the cooling water is avoided (which could lead, for example, to irregular slag flow and poor condensation process control). In some embodiments, the contactor incorporates a static mixer with mixing vanes to ensure vapor/liquid contact and cleaning of impurities from the vapor to the condensed phase 13. Accordingly, in some embodiments, the SSCC system of the present invention may be configured for partial condensation to concentrate vapor and remove bulk NCG. For example, a constant velocity probe, an isolation valve for the injection of heat removed condensate into the vapor sample line, an isolation valve for the injection of heat removed condensate from the vapor sample line, a pressure sensor in the vapor sample line, a flow sensor for the vapor sample, Flow control valve/isolation valve for steam sample, pressure sensor for contactor cooling water supply, check valve for contactor cooling water supply, flow control valve for steam contactor cooling water outlet, flow control valve for contactor cooling water outlet Temperature sensor, separator pressure sensor, separator condensate dump valve, separator condensate piping to sample cooler, accumulator vessel, condensate cooler, condensate sample cooler cooling water outlet piping, condensate sample cooler cooling water inlet isolation Valve, condensate sample cooler cooling water inlet flow switch, condensate sample cooler cooling water inlet piping, condensate sample temperature sensor, condensate sample piping outlet from cooler, slow heat pump, flow control valve/to slow heat pump Isolation valve for the supply air of flow rate sensor, pure water separation valve, pure water ion exchange cartridge, pure water ion exchange cartridge, vapor impurity analyzer(s) sample drain piping, programmable logic control (PLC) system, and human machine interface (HMI) ). Thus, the SSCC system of the present invention functions to remove/clean impurities from the vapor stream into the condensed phase. Thus, the SSCC system of the present invention lowers the detection limit of vapor purity analysis and removes interferences (eg, impurities) from the analytical process. For example, the detection limits typically achieved in geothermal steam using SSCC and commercial analyzer versus commercial analyzer alone are as follows:

Impurities SSSC used SSCC not used
Sodium 1ppb 20ppb
Chloride 1ppb 50ppb
Silica 1ppb 100ppb
Iron 1ppb 100ppb
In some embodiments, the SSCC system includes a high efficiency vapor/liquid separator 16. The high-efficiency vapor/liquid separator of the SSCC system of the present invention is capable of separating residual vapor and condensate so that in some embodiments only the concentrated and conditioned (gas-free) condensate stream is analyzed. used to separate samples. In some embodiments, the separator includes a tangential inlet to generate a cyclonic flow and a vapor outlet with a mist pad to capture residual moisture, separating residual vapor from condensate. Vapor/liquid separators are very efficient (e.g., only a very small proportion of the inlet condensate (e.g., less than 5%, less than 4%, less than 3%, less than 2%, less than 1%, or less) (less than 100%) is carried over into the residual exhaust steam). In some embodiments, the vapor/liquid separator has a separation efficiency of >95%, >96%, >97%, >98%, or >99%. In some embodiments, the vapor/liquid separator has a separation efficiency of >99% (eg, such that less than 1% of the inlet condensate is carried over into the residual exhaust vapor). In some embodiments, the SSCC system continuously monitors/measures the level of condensate within the separator. Multiple methods of monitoring/measuring condensate levels may be used, including, but not limited to, using magnetic level sensors and/or pressure level sensors 20. The SSCC system also includes one or more configurations for maintaining a constant level of condensate within the accumulator vessel 21, including, but not limited to, a variable speed drive (VSD) condensate metering pump 32. element. In some embodiments, the SSCC system cools the condensate sample from about 100° C. to about 30° C. in a single tube shell and tube heat exchanger (sample cooler) 22.

In some embodiments, the SSCC system of the present invention is configured to measure both the vapor sample flow and the condensed sample flow to calculate the concentration factor. In some embodiments, an enrichment factor is used to correct the analyzed concentration back to the original concentration of the impurity in the feed vapor. In some embodiments, the SSCC system supplies a portion (e.g., up to 50%) of the cooled condensate to a high pressure descending heat (DSH) pump before the VSD (variable speed drive) condensate pump 32. 30, configured to be drawn from the condensate line. DSH pumps are air-operated or electronic solenoid metering pumps. The DSH pump recirculates condensate upstream of the critical orifice meter 7 or flow control valve 9. The recycled condensate prevents the vapor sample from overheating after the critical orifice or flow control valve. Recirculated condensate will be generated by pressure drop through the vapor flow regulator. In some embodiments, the amount of condensate required to maintain the steam saturated with a small amount of residual moisture (~0.5%) after pressure drop is approximately 50% of the condensate produced by the contactor. %. In some embodiments, the SSCC system includes a temperature sensor 9, typically an electrical resistance temperature device (RTD), that measures the temperature of the steam after a steam flow regulator (e.g., a DSH pump). to ensure that sufficient condensate is injected to produce saturated steam conditions). For example, if the steam is superheated after the steam flow conditioner, impurities may accumulate in the sample line and reduce the apparent impurity concentration measured downstream by analyzer 39. Since the DSH pump condensate is recirculated in a closed loop, there is no net effect on the accumulator level sensor 20 or the condensate flow rate from the VSD condensate pump 32.

In some embodiments, the SSCC system is configured such that the condensate flow from the VSD pump passes through an electronic three-way solenoid valve 34 that directs the condensate to a drain or analyzer 39. In some embodiments, the flow rate of the condensate sample stream is measured by magnetic flow meter 35 as the stream is directed to analyzer 39. In some embodiments, a source of deionized (DI) water is provided during processing from a set of ion exchange cartridges 38. Pressurized DI water is allowed to flow to the analyzer when electronic solenoid valve 37 opens, which automatically causes three-way sample valve 34 to close. In this configuration, the SSCC continues to process samples, but the analyzer 39 measures the DI water flow and provides baseline "zero" data.

In some embodiments, the SSCC system includes a fully automated programmable logic control (PLC) control system 41. The PLC system can be configured to execute, control, monitor, transfer (eg, to other local or remote computer systems), and/or record data from any component of the SSCC system. For example, in some embodiments, a PLC system is configured to operate, control, monitor, transfer, and/or record all SSCC process data, including vapor sample and condensate flow rates. In some embodiments, a PLC system controls the amount of steam condensate to a preset value by controlling the flow of cooling water (control valve). In some embodiments, a PLC system controls the separator level by controlling a condensate flow control valve to the analyzer. In yet other embodiments, a PLC system calculates a concentration factor, X, for a sample of vapor. where X=vapor sample flow rate/condensate sample flow rate. In some embodiments, the SSCC systems of the present invention are utilized with geothermal steam power generation systems and/or equipment. The invention is not limited to any particular steam cycle power generation system, steam generator or industrial process steam system. Exemplary systems include geothermal, coal-fired, oil-fired, biomass and nuclear power plants, industrial steam heating and cooling systems, steam disinfection systems, and steam generators for enhanced oil recovery and other industrial applications. However, it is not limited to these.

In some embodiments, the SSCC system includes a vapor purity analyzer 39. The invention is not limited to any particular analyzer. In fact, there are a variety of commercially available analyzers that can be used with the present invention. In fact, any commercially available equipment designed to measure impurities in a sample of condensed vapor can be used. Exemplary analyzers include one or more analyzers manufactured by Hach, Loveland, CO, USA (e.g., the Hach Model 9245 Low Level Sodium Analyzer based on an ion-specific electrode (ISE); based on color spectrophotometry). Hach Model 5500sc low-level silica analyzer; Hach Model EZ2005 low-level total iron analyzer based on color spectrophotometry; and/or Hach Model TU5300 low-level turbidity (TSS) analyzer based on laser light scattering); Not limited to these.

I. Definitions As used herein, "about" is understood by those of skill in the art and varies to some extent depending on the context in which it is used. If there is a use of the term that is not obvious to one skilled in the art given the context in which it is used, "about" means up to plus or minus 10% of the particular term.

As used herein, the term "comprising" is intended to mean that the systems, devices, and methods include the listed elements but do not exclude others. Accordingly, it is contemplated that the systems, devices, and methods may include additional steps and features/elements.

The systems, apparatus, and methods of using the same are further described by reference to the following examples, which are provided by way of example only. The invention is not limited to the examples, but rather includes all variations that are obvious from the teachings provided herein. All publicly available documents referenced herein, including but not limited to US patents, are specifically incorporated by reference.

〔Example〕
(Example 1-SSCC laboratory test results)
Calculations compare the application of the SSCC system and process with partial vapor condensation of the present invention to the conventional application of full vapor condensate for on-line analytical applications, with nitrogen (N ₂ ) gas purge. was carried out to Although not utilized in conventional methods, acid addition was also modeled in the full condensation process to aid in the removal of residual CO ₂ and H ₂ S. The computer model used was specifically developed for liquid/gas distribution of H ₂ S, CO ₂ and NH ₃ in geothermal steam process applications (eg power plant condensers and gas removal). This program is called "OneBox", a subroutine of CNDSR, and was originally developed by Oleh Weres of Lawrence Berkeley Laboratories (1985, LBID-622).

Figure 3 shows the dissolved residual _CO2 concentration in a fully condensed vapor sample with and without the addition of acid to reduce the pH from the native state of 6.5 to 3.0. , shown as a function of the amount of _N2 purge gas passed through the condensate. The initial vapor composition used in the computer model was 10,000 ppm _CO2 , 180 ppm _H2S , and 100 ppm _NH3 . The initial steam composition is approximately mid-geothermal steam composition for non-condensable gases. As shown in Figure 3, the dissolved _CO2 concentration decreased rapidly with the first purge, but then plateaued after about 30 liters of gas purge volume and there was no significant benefit after about 50 liters. Typical _N2 purge gas flow rates in online analyzers are approximately 1 liter per minute (lpm), so volumes much greater than 5 or 10 liters are required to monitor impurities in the vapor in near real time. Not practical for some online analyzers (analysis should take less than 5 minutes per sample). At a purge volume of 10 liters, there was 6.5% of the total _CO2 still dissolved in the condensate, and at the same purge volume that lowered the pH to 3.0, there was still 4.0% dissolved. There is.

Figure 4 shows the dissolved residual _H2S concentration in a sample of fully condensed vapor with and without the addition of acid to reduce the pH from 6.5 to 3.0. as a function of the amount of _N2 purge gas passed through the object. The same vapor composition as shown in Figure 3 was used. Upon complete condensation without gas purge, approximately 30% of the total _H2S in the vapor was dissolved in the condensate. There is little advantage in adding acid without gas purging. After a purge volume of 10 liters, there is 14% of the total H ₂ S still dissolved in the condensate, and with the same purge volume that lowers the pH to 3.0, 11% is still dissolved. Regardless of pH, there is no significant advantage in reducing dissolved _H2S after approximately 30 liters of gas purge.

Controlled laboratory tests were also conducted to confirm the chemical modeling results regarding _H2S gas purge efficiency. FIG. 5 shows the residual H ₂ S dissolved and measured in a real steam condensate sample as a function of the amount of N ₂ purge gas, with and without acid addition for pH adjustment. In this case, the vapor condensed sample contained 180 ppm H ₂ S and 30 ppm NH ₃ . The measured silica content of the initial sample was 0.040 ppm, and 0.200 ppm was added to give a known concentration of 0.240 ppm to facilitate detection of silica in the presence of _H2S interference. The concentration of silica measured by molybdate colorimetry (the same used by all online analyzers for low level silica measurements in vapor) is plotted against the gas purge volume. As observed using the _H2S chemical modeling experiments and results described in Figures 4 and 5, the measured silica values decreased rapidly with the first 5 liters of gas purge, but with or without acid addition. , it flattened again at about 30 liters. The high silica value measured compared to the true value of 0.240 ppm was due to _H2S interference. Even after a gas purge of 120 liters with acid addition, the measured values are not close to the true values due to the interference of dissolved residual H ₂ S and the formation of turbidity due to the slow oxidation of this H ₂ S in the sample. It was almost double.

The SSCC system of the present invention first provides on-line vapor purity analysis that prevents interfering gas dissolution in the condensate. Figure 6 uses the same model and steam composition as described in Figures 3 and 4, and shows residual _H2 dissolved in partially condensed steam at 100 °C as a function of acid addition for pH adjustment. We show results calculated from a model of the SSCC process for S. Without addition of acid, only about 0.5% of the total _H2S in the vapor was dissolved in the condensate. When acid was added below pH 5, only 0.07% of the total _H2S in the vapor was dissolved in the condensate. This is more than two orders of magnitude less H ₂ S dissolved in the condensate than could be achieved with a complete condensation process using a N ₂ purge and acid addition.

Several prototypes of the SSCC system described herein were constructed and tested. The fully functional, automated SSCC depicted in the drawings and described herein was tested using a laboratory steam generation test loop to simulate power plant turbine steam. The SSCC was tested at full design flow rate (1 kg/h steam, 0.10 kg/h condensate), saturated and superheated steam temperatures up to 225° C. with inlet pressure of 6.5 bar (bara).

SSCC requires efficient separation of condensate produced from exhausted residual vapor. The impurity enrichment factor . Therefore, if the measured condensate flow rate is low due to liquid carryover with residual exhaust vapor, the enrichment factor X will be erroneously high. The SSCC was tested using a vapor test loop to measure the amount of liquid carryover from separator 9 into the vapor. A highly detectable tracer (eg, a fluorescent dye marker (eg, PTSA)) was dissolved only in the liquid phase (no vapor distribution) and was injected into the vapor stream upstream of contactor 6 by a precision metering pump. Samples of condensate produced throughout normal operation of the SSCC (inlet steam flow rate of 1 kg/h and (using an exchanger) were analyzed for tracer content. The results listed in Figure 7 show that the amount of liquid carryover by vapor from the separator was only about 0.2%. This was well below the level of measurement bias that would require mathematical corrections to the results. Typically, commercially available analyzers measure each impurity with an accuracy of +/-10% or less.

Tests were also conducted to directly measure the concentration factor and recovery efficiency of steam impurities by the SSCC process. A NaCl solution of known concentration (10.3 ppm) was injected upstream of the contactor 6 by a precision metering pump. The injection rate was determined gravimetrically using an electronic balance to measure the weight loss of the solution from the reservoir over time. The average injection rate of the solution was 9.8+/-0.1 g/min. The measured condensate flow rate produced by the SSCC during the test was 0.0994 g/min (0.100 lpm at 35°C). Under these conditions, the expected concentration of Na in the condensate was 1.02 ppm and the average measured concentration by the online sodium analyzer was 0.99 ppm, as shown in Figure 8. Again, the accuracy of the online analyzer was well below the level of measurement bias that would require mathematical correction of the given results. The actual Na concentration in the sample inlet vapor was 0.10 ppm based on a vapor flow rate of 1.0 kg/min and a known Na solution injection rate. Accordingly, in some embodiments, the present invention captures, concentrates, and retains non-volatile impurities in geothermal steam while effectively preventing dissolution of interfering non-condensable gases into the sample stream. This provides a highly efficient SSCC system for

It will be apparent to those skilled in the art that various modifications and variations can be made to the systems, devices, and methods of the present invention without departing from the spirit or scope of the invention. Therefore, it is intended that the present invention cover the modifications and variations of the invention provided they come within the scope of the appended claims and their respective equivalents.

FIG. 1 is a diagram illustrating the main components and subcomponents and overall structure of an SSCC system in one embodiment of the invention connected to an online stream purity analyzer. FIG. 2 is a diagram illustrating major components and subcomponents with electrical analog and digital signal connections (dashed lines, control inputs and signal outputs) between the components of the SSCC system in an embodiment of the invention. . FIG. 3 shows the calculated residual CO ₂ dissolved in fully condensed vapor as a function of the amount of N ₂ purge gas to degas the condensate, with and without acid addition for pH adjustment. Figure 4 shows the calculated residual _H2S dissolved in fully condensed vapor as a function of the amount of _N2 purge gas to degas the condensate, with and without acid addition for pH adjustment. . FIG. 5 shows the measured residual H ₂ S dissolved in a real steam condensate sample as a function of the amount of N ₂ purge gas, with and without acid addition for pH adjustment. Figure 6 shows calculations from a model of the SSCC process for residual _H2S dissolved in partially condensed steam at 100 °C as a function of acid addition for pH adjustment, using the same model and steam composition as Figures 3 and 4. Show the results. FIG. 7 shows the results of a test performed on the SSCC using a vapor test loop to determine the amount of liquid carryover from separator 9 to vapor. Figure 7 shows that the amount of liquid carried over by vapor from the separator was only about 0.2%. FIG. 8 shows the results of a test conducted to directly measure the concentration factor and recovery efficiency of steam impurities by the SSCC process. Figure 8 shows that under the conditions tested, the expected concentration of Na in the condensate was 1.02 ppm and the average measured concentration by the online sodium analyzer was 0.99 ppm.

Claims (26)

1. A method for measuring steam purity in a stream of feedstock steam, the method comprising:
a. one or more devices that maintain a uniform flow of the vapor sample through the uniform sample probe nozzle;
b. a slow heat pump following the constant velocity flow controller to prevent the vapor sample stream from being overheated;
c. a vapor contactor for condensing the vapor sample stream;
d . a vapor/condensate separator that separates the condensed sample stream from the residual vapor sample stream;
e. a condensed vapor sample flowmeter for measuring the flow rate of said condensed sample stream; and
f. A method comprising the use of an apparatus, including one or more analyzers, for measuring impurities. A method for measuring steam purity in a stream of feedstock steam, the method comprising:
a. obtaining a steam flow sample from said feedstock steam flow;
b. partially condensing the vapor stream sample to produce a condensed sample stream and a residual vapor stream sample from the vapor stream sample ;
c. separating the condensed sample stream from the residual vapor stream sample;
d. analyzing the condensed sample stream by detecting and/or measuring one or more impurities in the condensed sample stream;
e. measuring a flow rate of the vapor stream sample and a flow rate of the condensed sample stream;
f. calculating a concentration factor using the measured vapor flow sample flow rate and the condensed sample flow rate;
g. A method comprising using the enrichment factor to calculate a level of one or more impurities in the feed vapor stream. 3. The method of claim 2, wherein a vapor/liquid separator is used to separate the condensed sample stream from the residual vapor stream sample. 4. The method of claim 3, wherein the vapor/liquid separator has a separation efficiency of greater than 99%. 2. The one or more impurities are selected from the group consisting of sodium (Na), silica ( _SiO2 ), chloride (Cl), iron (Fe) and total suspended solids (TSS). 4. The method according to any one of items 4 to 4. Any of claims 2 to 5, wherein partially condensing the vapor stream sample prevents dissolution of non-condensable gas (NCG) from the vapor stream sample into the condensed sample stream. or the method described in paragraph 1. By preventing the dissolution of non-condensable gas (NCG) from the vapor stream sample into the condensed sample stream , the 7. The method of claim 6, wherein a more accurate measurement of impurities is provided. Calculating the level of the one or more impurities in the feed vapor stream using the enrichment factor allows measurement of the one or more impurities at a detection level of parts per billion. The method according to any one of claims 2 to 7, wherein: A method according to any one of claims 2 to 8, wherein bulk non-condensable gases are removed from the vapor stream sample by partially condensing the vapor stream sample. 10. A method according to any one of claims 2 to 9, wherein no air and/or nitrogen purge is used. A method according to any one of claims 2 to 10, wherein the flow of the vapor stream sample is controlled to maintain a constant flow rate. 12. A method according to any one of claims 2 to 11, wherein no ion exchange cartridge is utilized for preconcentration or pretreatment. 13. A method according to any one of claims 2 to 12, wherein the sample of the vapor stream is enriched by at least an order of magnitude by partially condensing the sample of the vapor stream. The raw material steam flow may be steam used for power generation, geothermal steam, steam used for oil recovery, steam used for heating, steam used for cooling, steam used for food processing, and steam used for medical purposes. A method according to any one of claims 2 to 13, wherein the steam is selected from the group consisting of steam used for sterilization applications. After step (a) and before step (b), the method further comprises using a slow heat pump to recirculate the condensate, wherein a metering pump is added to the sample vapor flow after use of the slow heat pump. 15. The method according to any one of claims 2 to 14, wherein a dilute acid is administered. 16. The method of claim 15, _wherein the dilute acid is HCl, _H2SO4 , acetic acid, or citric acid. Method according to any one of claims 2 to 16, wherein the sample of vapor is partially condensed under a precisely controlled condensation process in a single tube shell-and-tube heat exchanger. . A device for measuring the purity of steam, the device comprising:
a. one or more devices that maintain a uniform flow of the vapor sample through the uniform sample probe nozzle;
b. a slow heat pump following the constant velocity flow controller to prevent the vapor sample stream from overheating;
c. a vapor contactor for condensing the vapor sample stream;
d . a vapor/condensate separator that separates the condensed sample stream from the residual vapor stream sample;
e. a vapor condensed sample flow meter for measuring the flow rate of said condensed sample stream; and
f. An apparatus comprising one or more analyzers for measuring impurities. 19. The apparatus of claim 18, wherein the one or more devices for maintaining constant flow is a flow sensor having a flow control valve. 19. The apparatus of claim 18, wherein the one or more devices for maintaining uniform flow is a critical orifice with an upstream pressure sensor. Apparatus according to any one of claims 18 to 20, wherein the slow heat pump prevents the accumulation of impurities. Apparatus according to any one of claims 18 to 21, wherein the steam contactor partially condenses the steam sample stream. Partial condensation occurs under a precisely controlled condensation process using a static mixer to ensure contact and transfer of impurities from the vapor sample stream to the condensed sample stream. 23. The apparatus of claim 22. The vapor sample flow rate and the condensed sample stream flow rate are utilized to calculate an enrichment factor, where the enrichment factor is the vapor inlet sample flow rate/condensed outlet sample flow rate. 24. A device according to any one of claims 18 to 23, wherein the flow rate is equal to the flow rate. 25. The apparatus of claim 24, wherein the enrichment factor is used to correct the analyzed concentration to the original concentration of the impurity in the feed vapor. 4. The analyzer measures impurities selected from the group consisting of sodium (Na), silica ( _SiO2 ), chloride (Cl), iron (Fe) and total suspended solids (TSS). 26. The device according to any one of items 18 to 25.

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